US4953142A - Model-based depth processing of seismic data - Google Patents
Model-based depth processing of seismic data Download PDFInfo
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- US4953142A US4953142A US07/294,536 US29453689A US4953142A US 4953142 A US4953142 A US 4953142A US 29453689 A US29453689 A US 29453689A US 4953142 A US4953142 A US 4953142A
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- 238000012545 processing Methods 0.000 title claims abstract description 15
- 238000000034 method Methods 0.000 claims abstract description 39
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- 230000003068 static effect Effects 0.000 claims description 6
- 238000007598 dipping method Methods 0.000 claims description 4
- 238000012804 iterative process Methods 0.000 claims description 2
- 230000008569 process Effects 0.000 abstract description 4
- 150000003839 salts Chemical class 0.000 description 7
- 238000012937 correction Methods 0.000 description 6
- 230000000694 effects Effects 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 2
- 238000005755 formation reaction Methods 0.000 description 2
- 238000010348 incorporation Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- 238000013459 approach Methods 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 238000003384 imaging method Methods 0.000 description 1
- 238000013507 mapping Methods 0.000 description 1
- 238000003672 processing method Methods 0.000 description 1
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- 239000011435 rock Substances 0.000 description 1
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Classifications
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
- G01V1/282—Application of seismic models, synthetic seismograms
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V2210/00—Details of seismic processing or analysis
- G01V2210/60—Analysis
- G01V2210/61—Analysis by combining or comparing a seismic data set with other data
- G01V2210/614—Synthetically generated data
Definitions
- This invention relates to the processing of seismic data to determine the geological structure of the subsurface of the earth. More particularly, it relates to a method of depth processing seismic data to enhance structural information in areas of steep dip.
- Seismic data is accumulated by well known methods.
- seismic receivers or geophones are laid out along a seismic line at spaced intervals from a shotpoint which sends a wave of seismic energy into the earth.
- the energy generated by the source penetrates the layers of material in the subsurface of the area of interest, propagating at different speeds through different types of formations.
- secondary seismic energy is returned to the surface.
- the secondary energy signals are detected by the geophones which generate electrical signals representative of the amplitude of the secondary seismic energy.
- the sensor array is then moved along the line to a new position and the process is repeated, ultimately resulting in data from a large number of closely spaced geophone locations.
- the same basic approach is utilized in offshore exploration as well as on land.
- the signals generated by the geophones are processed in the field or at a later time in a data processing center to remove noise and extraneous signals so that only reflected signals remain, and the amplitude of the signals from each geophone is continuously recorded against time to produce seismograms.
- the reflected ray traces between the shotpoint and each geophone must be grouped and compared. The conventional way of doing this is to assume that a point halfway between the shotpoint and a receiver overlies the point on the subsurface layer of interest from which the reflection came. This point is known as the common mid point (CMP) or the common depth point (CDP).
- Traces are binned according to the CDP and are summed or stacked for purposes of data interpretation.
- the time it takes for the primary energy from the shotpoint to reach the horizon is equal to the time for the reflected energy to reach the receiver.
- Another way of locating the reflected energy in all three spatial directions is to use data from two-dimensional seismic lines and apply time migration corrections. This still does not take into account energy recorded from reflections originating out of the vertical plane of the seismic line, as would be encountered in an area of steep dips. Moreover, the data is still initially inexact due to the inherent drawbacks of the CDP theory discussed above.
- the invention broadly involves an iterative process involving the use of a seismic model to create synthetic traces binned according to their common reflection points rather than their common midpoints, and then changing the model after comparing the model data with the seismic data. This is done for each seismic line and is continued for a horizon of interest until the margin of error between the model and the seismic data is acceptable. Because of the effects of shallower horizons on deeper reflections, each major horizon in the model must be built from the top down.
- the subsurface reflection points of the synthetic model traces may be determined by computing three-dimensional synthetic shot records for the seismic lines being processed and estimating reflection tracks for the seismic lines.
- the common reflection points of the computed seismic shot traces are then determined and used to bin the actual seismic traces.
- the actual seismic traces are stacked and the actual seismic event is compared with the predicted model event so as to estimate the difference between the seismic travel time and the model travel time and the error in interval velocity.
- the model is then corrected according to this information.
- FIG. 1 is a schematic representation of a common midpoint or common depth point gather for a horizontal horizon
- FIG. 2 is a schematic representation of a common midpoint or common depth point gather for a sloping horizon
- FIG. 3 is a schematic representation of a common reflection point gather for a sloping horizon
- FIG. 4 is a representation of a salt dome model, showing the actual reflection points of energy used in producing a common midpoint gather along a seismic line;
- FIG. 5 is a representation of the salt dome model shown in FIG. 4, but showing the reflection point of energy used in producing a common reflection point gather;
- FIG. 6 is a flow chart of the method of the present invention as applied to a single horizon.
- FIG. 7 is a flow chart of the method of the present invention using the results of the seismic model of FIG. 6 to construct a model of a larger area of geological interest.
- the wavefront of acoustic energy emitted from source S is schematically shown as a ray following the primary path 10 to the point P on the horizontal horizon H.
- the path of the energy reflected from the horizon H up to the receiver R is indicated at 12.
- the point P is the common reflection point (CRP) for the various traces depicted.
- the midpoint M between the source S and the receiver R which as previously pointed out is known as the common midpoint (CMP) or the common depth point (CDP), can be seen to directly overlie the common reflection point P.
- CMP common midpoint
- CDP common depth point
- a sloping horizon As shown in FIG. 2, rays from a source S are reflected from the sloping horizon or dip D at a series of points P instead of at a single common point, this point spread sometimes being referred to as CDP smear. In this case a line normal to the midpoint M between the acoustic source S and the receiver R intersects the horizon D at a point N considerably spaced from the reflection points P. It will be appreciated that if the slope of the horizon is low the reflection points P will be both relatively closely spaced to each other and relatively close to the intersection point N.
- the disparity may be small enough so as not to seriously affect the accuracy of a CDP stack section. If the slope of the horizon is steep the reflection points P will be quite remote from the intersection point N and more widely separated from each other, and a CDP section could be quite inaccurate.
- the rays 10 are reflected from a common reflection point P on a dipping layer D. Even though the horizon is so steep that both the source S and the receiver R are located on the same side of a point N' directly overlying the point P, the energy received by the receivers R is reflected from the same point, thus eliminating the erroneous effects of CDP smear.
- FIGS. 4 and 5 The significance of utilizing CRP instead of CDP is illustrated more clearly by comparing FIGS. 4 and 5.
- FIG. 4 it can be seen that a CDP constructed from data generated along seismic line 14 overlying a salt dome model 16 beneath the area 17 has been based on reflections 12 coming from reflection locations P spaced hundreds of meters apart and from out of the plane of the seismic line. In spite of this, the energy will have been stacked together in the same CDP in accordance with conventional procedures.
- the model-based depth processing method of the present invention provides a practical way to generate CRP data in order to enhance structural information in areas of steep dip.
- CDP binning is not employed. Traces are binned instead according to the location of their reflection from the horizon being modeled. The reflection location is determined using the results of three-dimensional raytracing, and the model is considered correct when the synthetic seismic data from the model matches the seismic data in the binned domain. This matching is done with all available seismic lines covering the area of interest and, as previously pointed out, a separate sorting and stacking must be done for each major horizon in the model.
- the model is built from the top down because the effects of shallower horizons on deeper reflections can be very important. Since in some areas one seismic line can generate multiple reflection paths, each path needs to be compared to the seismic data independently, thus requiring a new sort and stack operation for each reflection path from every line.
- the first step of the invention is to estimate from available data a geological structural model 20 of the shallowest horizon of interest.
- the model would normally be produced from standard seismic processed data 22, well data 24 if available, and any other pertinent geological data 26 available.
- the geologic horizon of the structural model must correspond to the seismic horizon.
- This estimate is then entered into a three-dimensional seismic model 28, and three-dimensional shot records 30 are computed from the seismic model for the seismic lines being processed.
- One or more reflection tracks 32 are then estimated from the synthetic shot records.
- a reflection track 32 is shown in FIG. 4 to illustrate that this is the path along which reflection points P for the seismic line 14 are located. It can be seen to be a typically irregularly shaped path due to the compound slope of the horizon of interest.
- the estimating of the geologic model, the creation of a three-dimensional seismic model and the incorporation of the geological data into the three-dimensional seismic model involve procedures well known by those skilled in the art.
- the computation of three-dimensional synthetic shot records and the estimating of reflection tracks to fit the seismic data for the seismic lines being processed, while not commonly known in industry, is, however, readily understood by geophysicists. Since these procedures are well known and since the invention is concerned not with such procedures themselves but with the overall method of depth processing seismic data utilizing the results of these steps, there is no need to go into a detailed explanation as to how these various functions are carried out.
- the next step of the invention is to set up bins 34 along the reflection track 32 and to assign bin numbers 36 to each actual seismic trace from the seismic shot records 38.
- a standard static conversion 40 is calculated to convert the two-way travel time of the traces to depth, and both the bin number and static conversion figure are incorporated into the data of each trace.
- the traces 38 are next sorted into common reflection point bins 42 and stacked as at 44 in accordance with conventional stacking procedures.
- the binned or sorted data and the stacked data are then inspected as at 46 and the difference between the seismic travel time and the model travel time is estimated, as is the error in internal velocity, such estimates being carried out by well known procedures.
- the three-dimensional seismic model is then changed as at 48 so as to match the actual seismic data, and the entire procedure is repeated as many times as necessary until the error in travel time and velocity is below the minimum required error, resulting in an accurate model for the horizon of interest.
- the process is begun again for the next lower major seismic event by creating a three-dimensional seismic model 50 in the same manner as described above, including input from the completed three-dimensional seismic model 28 of the next higher horizon.
- the geological area which includes the horizons 28 and 50 can now be modeled as at 52. If there are other lower horizons of interest, such as that indicated at 54, they are sequentially modeled and included in the model of the geological area until the final seismic model 56 accurately portrays the entire geological area of interest.
- Seismic data produced in accordance with the invention may look considerably different than data based on CDP stacks. For one thing the fold of the seismic data varies considerably along the seismic line, which is to be expected since the subsurface sampling along a two-dimensional seismic line can be very erratic. Another difference is that the data is now binned quite differently than by the common depth point or common midpoint method. The seismic data is now located according to its reflection track and does not correspond to the surface location of the seismic line. To locate the data it is necessary to have a map of the reflection path used to sort the line.
- a CRP stack produced by the method of the invention is only strictly valid for the horizon being modeled and for some relatively small window in time around that layer.
- Other horizons that have a similar dip direction as the reflection path of the layer being modeled will be found on the stack in a partially migrated position. Although such horizons may not be binned exactly as they should, they will be binned more correctly than they would be according to the CDP data.
- the CRP method of the invention now makes it possible to represent steep dips of about 45° to 80°, in contrast to the CDP method which is not capable of representing dips of greater than about 60°.
- the CRP method represents steep dips, even in the range of slopes normally represented by the CDP method, much more accurately.
- CDP is limited to two-dimensional data, requiring the seismic line to be oriented to the direction of the dip
- the CRP method of the invention allows three-dimensional data to be utilized. Further, significant depth differences have been observed between CRP and CDP data in geologic areas of steep dip, with the representation produced by the present invention being the more accurate.
- the invention not only enhances seismic data in areas where the geology includes steep or rapidly changing geometry, but permits the incorporation and understanding of three-dimensional effects using two-dimensional data, and is especially useful in prospect or reservoir delineation.
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Abstract
Description
Claims (7)
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US07/294,536 US4953142A (en) | 1989-01-06 | 1989-01-06 | Model-based depth processing of seismic data |
AU43711/89A AU612552B2 (en) | 1989-01-06 | 1989-10-24 | Model-based depth processing of seismic data |
EG58589A EG19281A (en) | 1989-01-06 | 1989-11-27 | Model based depth processing of seismic data. |
GB8926722A GB2226884A (en) | 1989-01-06 | 1989-11-27 | Model-base depth processing of seimic data |
TNTNSN89138A TNSN89138A1 (en) | 1989-01-06 | 1989-12-21 | MODELING PROCESSING OF DEEP-RELATED SYSMIC DATA |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US07/294,536 US4953142A (en) | 1989-01-06 | 1989-01-06 | Model-based depth processing of seismic data |
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US4953142A true US4953142A (en) | 1990-08-28 |
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US07/294,536 Expired - Lifetime US4953142A (en) | 1989-01-06 | 1989-01-06 | Model-based depth processing of seismic data |
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US (1) | US4953142A (en) |
AU (1) | AU612552B2 (en) |
EG (1) | EG19281A (en) |
GB (1) | GB2226884A (en) |
TN (1) | TNSN89138A1 (en) |
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EP0515188A2 (en) * | 1991-05-23 | 1992-11-25 | Western Atlas International, Inc. | A method for attenuating undesirable data, such as multiples, using constrained cross-equalization |
US5189643A (en) * | 1992-03-05 | 1993-02-23 | Conoco Inc. | Method of accurate fault location using common reflection point gathers |
US5200928A (en) * | 1991-11-07 | 1993-04-06 | Chevron Research And Technology Company | Method for using mode converted P- to S- wave data to delineate an anomalous geologic structure |
US5229940A (en) * | 1992-01-29 | 1993-07-20 | Conoco Inc. | Method of extracting three dimensional information from a grid of two dimensional seismic data |
WO1994028439A1 (en) * | 1993-05-28 | 1994-12-08 | Western Atlas International, Inc. | Quality assurance of spatial sampling for dmo |
US5466157A (en) * | 1991-06-12 | 1995-11-14 | Atlantic Richfield Company | Method of simulating a seismic survey |
US5838634A (en) * | 1996-04-04 | 1998-11-17 | Exxon Production Research Company | Method of generating 3-D geologic models incorporating geologic and geophysical constraints |
US6021094A (en) * | 1998-12-03 | 2000-02-01 | Sandia Corporation | Method of migrating seismic records |
US6246963B1 (en) | 1999-01-29 | 2001-06-12 | Timothy A. Cross | Method for predicting stratigraphy |
US6577955B2 (en) * | 2001-03-05 | 2003-06-10 | Compagnie Generale De Geophysique | Methods of tomographically inverting picked events on migrated seismic data |
US20030115029A1 (en) * | 2001-12-13 | 2003-06-19 | Calvert Craig S. | Method for locally controlling spatial continuity in geologic models |
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US20030132934A1 (en) * | 2001-12-12 | 2003-07-17 | Technoguide As | Three dimensional geological model construction |
US20040138819A1 (en) * | 2003-01-09 | 2004-07-15 | Goswami Jaideva C. | Method and apparatus for determining regional dip properties |
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1989
- 1989-01-06 US US07/294,536 patent/US4953142A/en not_active Expired - Lifetime
- 1989-10-24 AU AU43711/89A patent/AU612552B2/en not_active Ceased
- 1989-11-27 GB GB8926722A patent/GB2226884A/en not_active Withdrawn
- 1989-11-27 EG EG58589A patent/EG19281A/en active
- 1989-12-21 TN TNTNSN89138A patent/TNSN89138A1/en unknown
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Also Published As
Publication number | Publication date |
---|---|
AU4371189A (en) | 1990-07-12 |
GB2226884A (en) | 1990-07-11 |
AU612552B2 (en) | 1991-07-11 |
GB8926722D0 (en) | 1990-01-17 |
EG19281A (en) | 1995-03-30 |
TNSN89138A1 (en) | 1991-02-04 |
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